Alberta, Saskatchewan, and Manitoba Natural Gas Price Outlook for Farm Operations — Input Prices

Input Prices | Natural Gas and Energy | April 24, 2026

The Structural Condition

Prairie farm operations that heat livestock barns, dry grain, or run large heated facilities are entering a structural shift in their natural gas cost base. For most of the period from 2016 to 2024, Alberta’s AECO benchmark price — the upstream reference for natural gas costs across the Prairie provinces — traded at historically low levels, often below $2.00/GJ and frequently at significant discounts to the U.S. Henry Hub benchmark. That era is ending.

The structural driver is the commissioning of LNG Canada Phase 1 at Kitimat, B.C., which shipped its first cargo in mid-2025. The project provides the Western Canada Sedimentary Basin (WCSB) with its first large-scale outlet to international LNG markets, gradually pulling gas molecules away from the basin’s historically captive domestic-and-U.S.-export market and toward higher-value Pacific destinations. According to the Alberta Energy Regulator’s ST98 Energy Outlook, AECO-C averaged only $1.45/GJ in 2024 — down 47% from 2023 levels following the collapse of the global energy price spike — and the AER’s base-case forecast moves AECO-C to $2.71/GJ in 2025, rising to $3.82/GJ in 2026, and continuing toward $4.37/GJ by 2034 as LNG export capacity expands.

The transition is not clean or linear. Western Canadian natural gas production hit record levels in 2025, averaging approximately 19.24 Bcf/d — output from prolific Montney and Duvernay tight gas plays that has persistently outpaced domestic demand and export capacity. According to analysis from Morningstar DBRS (February 2026), markets fed by the WCSB remained in near-term oversupply in early 2026, holding AECO prices near C$2.50/GJ despite LNG Canada’s start-up. LNG Canada’s first train operated below design capacity through much of 2025 due to technical commissioning issues, consuming approximately 400 MMcf/d against an expected 1 Bcf/d. Meanwhile, Henry Hub natural gas spot prices on April 24, 2026 stood at approximately US$2.55/MMBtu — the lowest since October 2024 — pressured by ample U.S. storage inventories running approximately 7% above the five-year average and mild spring weather suppressing heating demand.

The near-term and medium-term signals are therefore divergent. Spot and current-delivery prices remain soft due to WCSB oversupply and weak North American spring demand. The forward price trajectory — anchored by growing LNG export demand, projected production discipline past 2026, and additional LNG capacity from Woodfibre LNG and Cedar LNG later this decade — points toward a structurally firmer gas cost environment for Prairie operations than producers have experienced in the past decade.

Current Price Levels by Province

Alberta

Alberta Agriculture and Irrigation’s Monthly Farm Input Price Survey (May 2025, the most recently published edition) recorded farm natural gas at $2.52/GJ (excluding service and delivery charges, provincial rebate deducted). This compares to $2.30/GJ in April 2025 and $1.79/GJ in May 2024 — a 41% year-over-year increase at the farm gate level.

Source: Alberta Agriculture and Irrigation, Trade, Economics and Data Analytics Branch, Statistics and Data Development Section. Alberta Average Farm Input Prices.

The Alberta Energy Regulator’s base-case forecast places AECO-C at $3.82/GJ for 2026 — representing a further directional increase from the May 2025 farm retail benchmark, though actual farm retail prices will diverge from the AECO spot price depending on utility margin, delivery charges, and provincial rebate structures.

Source: Alberta Energy Regulator. AECO-C Price Forecast, ST98 Energy Outlook.

Saskatchewan

SaskEnergy is Saskatchewan’s provincial natural gas distributor and passes commodity costs through to customers without markup. SaskEnergy’s commodity rate has been set at $3.20/GJ (effective October 1, 2023), unchanged through the period covered by publicly available rate publications. SaskEnergy purchases approximately 70% of its natural gas supply from Alberta, with flows entering Saskatchewan through the Empress Hub at the provincial border. SaskEnergy’s price risk management strategy uses contracted forward purchases to smooth commodity rate volatility, insulating Saskatchewan customers from the extremes of monthly spot market movements.

Importantly, as of April 1, 2025, Saskatchewan residential and commercial customers receive a zero charge for the federal carbon tax on natural gas — a meaningful change to the effective delivered cost for farm operations previously subject to the fuel charge.

Source: SaskEnergy. SaskEnergy Business Rates; SaskEnergy Bill Estimator (Federal Carbon Tax Note).

Manitoba

Manitoba Hydro distributes natural gas in Manitoba under regulation of the Manitoba Public Utilities Board (PUB). Manitoba Hydro passes gas commodity costs to customers without markup, adjusting rates quarterly (February, May, August, and November). The PUB approved a revised gas commodity rate effective February 1, 2026, increasing the commodity rate from 8.05¢/m³ to 8.39¢/m³, with the delivery rate moving from 15.37¢ to 15.38¢/m³. Manitoba Hydro’s gas supply is sourced from the AECO market, meaning WCSB supply conditions and AECO pricing directly feed into Manitoba farm gas costs through each quarterly rate review.

Source: Manitoba Hydro. Manitoba Hydro Rates and Charges; Manitoba Hydro Residential Rates — Gas Commodity.

Production Economics Implications

Natural gas is a material operating cost for three categories of Prairie farm operations:

Climate-controlled livestock facilities — broiler and turkey barns (heating required October through April; ventilation year-round), laying hen facilities (year-round climate control), hog barns in farrow-to-finish configuration (year-round heating and ventilation), and dairy operations (milking equipment, cooling systems, barn heating). For these operations, natural gas is not a discretionary input — it is a fixed production requirement with no short-term substitution.

At Alberta’s May 2025 farm retail price of $2.52/GJ — up 41% from the same month in 2024 — operations consuming 500 GJ annually (a moderate barn footprint) are facing approximately $365 more in annual gas costs than at the year-ago price. At 1,000 GJ annually (a larger or multi-barn operation), that increases to approximately $730. The AER’s base-case forecast of $3.82/GJ for 2026 implies a further step-up: at that price level, the same 500 GJ operation would pay $1,910/year for commodity gas alone, compared to approximately $895 at 2024 average prices — a cumulative increase of over $1,000 per year if the AER trajectory holds.

Grain drying operations — operations drying corn, canola, or cereal grains in wet harvest years carry significant natural gas exposure. Grain dryer gas consumption varies substantially by crop moisture conditions, dryer type, and throughput, but can represent a multi-thousand dollar annual cost item in high-moisture years.

Dairy operations specifically — dairy barn heating, milk cooling compressors (run from natgas powered generators), and hot water systems for cleaning are continuous gas loads. The directional increase in gas costs is part of the broader input cost picture for dairy operations and connects directly to the companion dairy cost analysis referenced in the cross-links below.

The carbon tax removal in Saskatchewan is the one substantive cost relief signal in this picture. The elimination of the federal fuel charge on natural gas for Saskatchewan residential and commercial customers (including farms) as of April 1, 2025 partially offsets the commodity price increase direction in that province. Alberta agricultural producers have a separate fuel charge exemption structure for on-farm fuel use; producers should confirm their eligibility with their input supplier or agricultural financial advisor.

Pre-Buy and Timing Considerations

The forward curve structure for AECO natural gas shows contango — futures prices for winter 2026-27 delivery are higher than current spot. This is the normal seasonal pattern (winter premium for heating demand) reinforced by the structural LNG-driven upward trajectory. Henry Hub futures as of mid-March 2026 showed April 2026 near US$3.03/MMBtu and December 2026 near US$4.70/MMBtu — a clear winter premium.

For operations with the ability to contract forward natural gas supply at fixed rates, the current spring spot softness offers a possible opportunity to lock in gas supply ahead of the winter heating season. Manitoba Hydro and some Alberta retail gas providers offer fixed-rate contract options for farm and commercial customers. SaskEnergy’s commodity rate is set by the utility’s own purchase contracting and is not directly lockable by farm customers, though independent natural gas marketers serve the Saskatchewan market and may offer fixed-rate options.

The critical caveat is that the medium-term forward trajectory is upward based on AER and industry projections tied to LNG export ramp-up. The current spring softness may represent the low end of the AECO price range for the next several years — or it may persist if WCSB oversupply continues to outpace LNG demand pull through 2026. The timing of LNG Canada’s full ramp to design capacity is the key swing variable. Until that ramp is confirmed, forecasts carry significant uncertainty.

Input purchase timing decisions involve individual farm financial and agronomic factors. This analysis identifies market conditions only. Consult your input supplier and financial advisor before making purchase commitments.

Tags: AECO natural gas price, Alberta farm gas costs, SaskEnergy commodity rate, Manitoba Hydro gas rates, LNG Canada, barn heating costs, livestock energy costs, Prairie farm input prices, nitrogen fertilizer feedstock, Alberta Energy Regulator

This post was produced with AI assistance. All sources are attributed and linked. Western Farm Report editorial standards apply.